Volume 1.
Figure 2-1. Structure of oil production in Russia in 2000
Figure 2-2. Structure of oil production in Russia in 2006
Figure 2-3. Crude oil production and production drilling in Russia, 1990-2006
Figure 2-5. Oil production and production drilling in Russia and global oil prices, 1990-2006
Figure 2-6. Oil production and production drilling in Russia and global oil prices, 1990-2015
Figure 2-7. Dynamics of oil production in 1991-2006 (% vs. previous year)
Figure 2-10. Balance of oil distribution in Russia, 2000-2006 (millions of tons)
Figure 2-11. Balance of gas distribution in Russia, 2000-2006 (billions of cubic meters)
Figure 3-1. Drilling in key regions, 2001-2006 (thousands of meters)
Figure 3-2. Prospecting and exploratory drilling, 2001-2006 (thousands of meters)
Figure 3-3. Prospecting and exploratory drilling in key regions in 2006 (%)
Figure 3-4. Production drilling in key regions, 2001-2006 (thousands of meters)
Figure 3-5. Effect of production drilling in Russia per 1,000 meters of drilling in 1,000 tons, 2000-2006
Figure 3-6. Estimated daily flow of new oil wells in Russia, 2000-2006 (tons per day)
Figure 3-7. Additional production from production drilling and intensification methods in Russia, 2004-2006
Figure 3-8. Daily production and daily drilling footage, 2002-2007
Figure 3-9. Daily drilling meterage by month, 2002-2007 (1,000 meters per day)
Figure 3-11. Horizontal drilling in Russia, 2001-2006 (thousands of meters)
Figure 3-12. Volumes of well servicing/well workovers in Russia, 2001-2006 (operations)
Figure 3-13. Structure of the well servicing/well workover portfolio in Russia, 2001-2006, (%)
Figure 3-14. Coverage of the total producing wells stock with well servicing/well workover operations in Russia, 2001-2006 (thousands of wells)
Figure 3-15. The coverage of producing well stock with well servicing/well workover operations in Russia, 2001-2006 (thousands of wells)
Figure 3-16. Market size in million of hours (the left-hand side index line) and the average duration of light workovers (the right-hand side index line) in Russia, 2001-2006 (crew-hours)
Figure 3-17. Market size in million hours (left-hand side index line) and the average duration (the right-hand side index line) of heavy workovers in Russia, 2001-2006 (crew-hours)
Figure 3-18. Number of well servicing/well workover crews in Russia, 2001-2006
Figure 3-19. Operations per 1 well-servicing crew (left-hand side) and well-workover crew (the right-hand side) in Russia, 2001-2006 (operations per year)
Figure 3-20. Operations per 1 well-servicing crew in 1,000 hours (left-hand side) and capacity-utilization rate of a well-servicing crew (right-hand) in Russia, 2001-2006
Figure 3-21. 1,000 hours per 1 heavy workover crew (left-and side) and the capacity-utilization rate of a well workover crew (right-hand side index line) in Russia, 2001-2006
Figure 3-22. Additional production due to activities of well servicing/well workover and the contribution of the activities into additional production, 2004-2006 (thousands of tons)
Figure 3-23. Number of operations of production intensification in Russia, 2001-2006 (thousands of operations and %)
Figure 3-24. Number of hydraulic fracturing operations in existing well stock in Russia, 2001-2006
Figure 3-25. Effectiveness of hydro fracs operations in existing well stock in Russia, 2004-2006
Figure 3-26. Number of operations impacting the effective drainage area and their effectiveness in Russia, 2001- 2006
Figure 3-27. Number of operations for optimization of artificial lift and their effectiveness in Russia, 2001-2006
Figure 3-28. Water injection in reservoirs and water injection per ton of lifted oil in Russia, 2000-2006
Figure 3-29. Active injection wells stock and water injection per injection well in Russia, 2000-2006
Figure 3-30. Evaluation of main oilfield services equipment production in current prices (Rosstat) (left-hand side index line - millions US dollars) and cumulative inflation (right-hand side index line - %)
Figure 3-31. Estimated dynamics of production of main equipment in standard prices of 2005 (2005 = 100%)
Figure 3-32. Production of drilling rigs and well workover/well servicing units, 2000-2006 (units)
Figure 3-33. Production of cementing units and pumping units for hydro fracs, 2000-2006 (units)
Figure 3-34. Production of wellhead and Christmas tree fittings, 2000-2006 (units)
Figure 3-35. Production of artificial lift pumps in Russia, 2001-2006 (units)
Figure 3-36. Production of deep well sucker-rod pumps and ESP Systems in Russia, 2001-2006 (units)
Figure 3-37. Stock of producing wells by type of artificial lift, 2001-2006 (units)
Figure 3-38. Production of rod pump surface units in Russia, 2001-2006 (units)
Figure 3-39. Production of well logging aggregates, 2002-2006 (units)
Figure 4-1. Oilfield services market structure in 2006
Figure 4-2. Oilfield services market dynamics, 2001-2006, (millions of US dollars)
Table 4-3. Oilfield market dynamics in key segments, 2001-2006
Figure 4-4. Input of key segments in incremental market growth, 2001-2006 (millions of US dollars)
Figure 4-5. Average annual growth in key industry segments
Figure 4-6. Change in market structure, 2001-2006
Figure 4-7. Sidetracking market estimates, 2001-2006 (millions of US dollars)
Figure 4-8. Geophysical surveys (logging) market, 2001-2006 (millions of US dollars)
Figure 4-9. Regional structure of oilfield service market, 2001-2006 (excluding seismic)
Figure 4-10. Production of key equipment categories in Russia in 2001-2006 in real $ ‘000 at average exchange rate for corresponding year
Figure 4-11. Apparent market shares for oilfield services equipment in 2006
Figure 5-1. Oil production by region, 2001-2006 (millions of tons)
Figure 5-2. Share in production by region (2006 versus 2001)
Figure 5-4. Regional shares in key activities in 2006 (%)
Figure 5-5. Production drilling in key regions, 2001-2006 (thousands of meters)
Figure 5-6. Production drilling by key region (as % of total)
Figure 5-7. Commissioning of production wells by key region (tons/day)
Figure 5-8. Production wells completions in key regions, 2001-2006 (units)
Figure 5-9. Commissioning of horizontal wells by region, 2001-2006 (units)
Figure 5-10. Well servicing and workover jobs by key region, 2001-2006 (thousands of operations)
Figure 5-11. Production wells, 2001-2006
Figure 5-13. Hydraulic fracturing jobs on the current declining well stock by region, 2004-2006 (%)
Figure 5-14. Oil production in KMAD by company, 2001-2006 (thousands of tons)
Figure 5-15. Oil production in KMAD – Key production activities, 2001-2006 (thousands of tons)
Figure 5-16. Production drilling in KMAD by company, 2001-2006 (thousands of meters)
Figure 5-17. Commissioning of new production wells in KMAD, 2001-2006 (wells)
Figure 5-18. Estimates of daily flow rates from new wells and average depths in KMAD, 2001-2006
Figure 5-19. Apparent average well depth in KMAD, 2001-2006, exclusive of horizontal drilling (thousands of meters)
Figure 5-20. Horizontal drilling in KMAD by company, 2001-2006 (thousands of meters)
Figure 5-21. Exploration drilling in KMAD by company, 2001-2006 (thousands of meters)
Figure 5-22. Production well stock and injection well stock, 2001-2006
Figure 5-23. Active wells in the total well stock in KMAD, 2001-2006 (%)
Figure 5-24. Well servicing operations jobs in KMAD, 2001-2006
Figure 5-25. Well workover jobs in KMAD by company, 2001-2006 (heavy workovers)
Table 5-26. Well workovers in KMAD by key player and growth rates, 2003-2006 (units)
Figure 5-27. Artificial lift optimization jobs in KMAD by company, 2001-2006 (units)
Figure 5-28. Effectiveness of artificial lift optimization activities in KMAD, 2001-2006 (incremental flow rate—tons per day)
Figure 5-29. Bottom-hole zone treatment jobs in KMAD by company, 2001-2006 (operations)
Figure 5-30. Effectiveness of bottom-hole zone treatment activities in KMAD, 2001-2006 (flow rate- tons per day)
Figure 5-31. Number of hydraulic fracturing jobs in KMAD by company, 2004-2006 (units)
Figure 5-32. Effectiveness of hydraulic fracturing activities in KMAD, 2004-2006 (flow rate- tonsper day)
Figure 5-33. Water injectionin KMAD by company, 2001-2006 (thousands of cubic meters)
Figure 5-34. Water injection per ton of production in KMAD, 2001-2006 (tons of water per ton of oil)
Figure 5-35. Gas production in YNAD by company, 2002-2006 (billions of cubic meters)
Figure 5-36. Production of crude oil and gas condensate in YNAD by company, 2001-2006 (thousands of tons)
Figure 5-37. Oil production in YNAD – Key production activities, 2001-2006 (thousands of tons)
Figure 5-38. Production drilling in YNAD by company, 2001-2006 (thousands of meters)
Figure 5-39. Commissioning of new production wells in YNAD by company, 2001-2006 (units)
Figure 5-40. Estimates of flow rates from new wells and average depths in YNAD, 2001-2006
Figure 5-41. Commissioning of horizontal wells in YNAD by company, 2001-2006 (units)
Figure 5-42. Exploration drilling in YNAD by company, 2001-2006 (thousands of meters)
Figure 5-43. Production and injection well stock in YNAD, 2001-2006
Figure 5-44. Producing wells and operational water injection wells versus total production wells in YNAD, 2001-2006 (%)
Figure 5-45. Well-servicing jobs in YNAD by company, 2001-2006 (light workovers)
Figure 5-46. Well-workover jobs in YNAD by company, 2001-2006 (heavy workovers)
Figure 5-48. Artificial lift optimization jobs in YNAD by company, 2001-2006 (units)
Figure 5-49. Effectiveness of artificial lift optimization activities in YNAD, 2001-2006 (incremental daily flow rate-tons per day)
Figure 5-50. Bottom-hole zone treatment jobs in YNAD by company, 2001-2006 (operations)
Figure 5-51. Effectiveness of Bottom-hole zone treatment activities in YNAD, 2001-2006 (incremental daily flow rate- tons per day)
Figure 5-52. Number of hydraulic fracturing jobs in YNAD by company, 2004-2006 (units)
Figure 5-53. Effectiveness of hydraulic fracturing activities in YNAD, 2004-2006 (flow rate- tons per day)
Figure 5-54. Water injection in YNAD by company, 2001-2006 (thousands of cubic meters)
Figure 5-55. Water injection per ton of production in YNAD, 2001-2006 (tons of water per ton of oil)
Figure 5-56. Oil and gas condensate production in the Volga-Urals region by company, 2001-2006 (thousands of tons)
Figure 5-57. Oil production in the Volga-Urals region – Key production activities, 2001-2006 (thousands of tons)
Figure 5-58. Production drilling in the Volga-Urals region by company, 2001-2006 (thousands of meters)
Figure 5-59. Completion of new production wells in the Volga-Urals region by company, 2001-2006 (units)
Figure 5-60. Estimates of flow rates from new wells and average depths in the Volga-Urals region, 2001-2006
Figure 5-61. Completion of horizontal wells in the Volga-Urals region by company, 2001-2006 (units)
Figure 5-62. Exploration drilling in the Volga-Urals region by company, 2001-2006 (thousands of meters)
Figure 5-63. Operating well stock in the Volga-Urals region, 2001-2006 (units)
Figure 5-64. Active wells as percentage of total operating wells in the Volga-Urals region, 2001-2006 (units)
Figure 5-65. Well-servicing jobs in the Volga-Urals region by company, 2001-2006 (light workovers – number of operations)
Figure 5-66. Well-workover jobs in the Volga-Urals region, 2001-2006 (heavy workovers – number of operations)
Figure 5-67. Artificial lift optimization jobs in the Volga-Urals region by company, 2001-2006 (units)
Figure 5-68. Effectiveness of artificial lift optimization activities in the Volga-Urals region, 2001-2006 (incremental flow rate- tons per day)
Figure 5-69. Bottom-hole zone treatment jobs in the Volga-Urals region by company, 2001-2006 (units)
Figure 5-70. Effectiveness of bottom-hole zone treatment activities in the Volga-Urals region, 2001-2006 (incremental flow rates—tons per day)
Figure 5-71. Number of hydraulic fracturing jobs in the Volga-Urals region by company, 2004-2006 (number of operations)
Figure 5-72. Effectiveness of hydraulic fracturing activities in the Volga-Urals region, 2004-2006 (incremental flow rate- tons per day)
Figure 5-73. Effectiveness of hydraulic fracturing activities by key company in the Volga-Urals region by company, 2004-2006 (incremental flow rate - tons per day)
Figure 5-74. Water injection in the Volga-Urals region by company, 2001-2006 (thousands of cubic meters)
Figure 5-75. Water injection per ton of production in the Volga-Urals region, 2001-2006 (tons of water per ton of oil)
Figure 5-76. Oil and gas condensate production in Timan-Pechora by company, 2001-2006 (thousands of tons)
Figure 5-77. Oil production in Timan-Pechora – Key production activities, 2001-2006 (thousands of tons)
Figure 5-78. Production drilling in Timan-Pechora by company, 2001-2006 (thousands of meters)
Figure 5-79. New production wells completion in Timan-Pechora by company, 2001-2006 (units)
Figure 5-80. Estimates of flow rates from new wells and average depths in Timan-Pechora, 2001-2006
Figure 5-81. Commissioning of horizontal wells in Timan-Pechora by company, 2001-2006 (units)
Figure 5-82. Exploration drilling in Timan-Pechora by company, 2001-2006 (thousands of meters)
Figure 5-83. Production well stock and water injection wells stock in Timan-Pechora, 2001-2006 (units)
Figure 5-84. Producing wells as percentage of total operating wells in Timan-Pechora, 2001-2006 (%)
Figure 5-85. Well-servicing jobs in Timan-Pechora by company, 2001-2006 (light workovers – number of operations)
Figure 5-86. Well-workover jobs in Timan-Pechora by company, 2001-2006 (heavy workovers – number of operations)
Figure 5-87. Artificial lift optimization jobs in Timan-Pechora by company, 2001-2006 (units)
Figure 5-88. Effectiveness of artificial lift optimization activities in Timan-Pechora, 2001-2006 (incremental flow rate- tons per day)
Figure 5-89. Bottom-hole zone treatment jobs in Timan-Pechora by company, 2001-2006 (units)
Figure 5-90. Effectiveness of bottom-hole zone treatment activities in Timan-Pechora, 2001-2006 (flow rate- tons per day)
Figure 5-91. Number of hydraulic fracturing jobs in Timan-Pechora by company, 2004-2006 (units)
Figure 5-92. Effectiveness of hydraulic fracturing activities in Timan-Pechora, 2004-2006 (incremental flow rate-tons per day)
Figure 5-93. Water injection in Timan-Pechora by company, 2002-2006 (thousands of cubic meters)
Figure 5-94. Water injection per ton of production in Timan-Pechora, 2002-2006 (tons of water per ton of oil)
Figure 5-95. Oil production in the North Caucasus by company, 2001-2006 (thousands of tons)
Figure 5-96. Oil production in the North Caucasus – Key production activities, 2001-2006 (thousands of tons)
Figure 5-97. Production drilling in the North Caucasus by company, 2001-2006 (thousands of meters)
Figure 5-98. New production wells completions in the North Caucasus by company, 2001-2006 (units)
Figure 5-99. Estimates of flow rates from new wells and average depths in the North Caucasus, 2001-2006
Figure 5-100. Exploration drilling in the North Caucasus by company, 2001-2006 (thousands of meters)
Figure 5-101. Total operating well stock in the North Caucasus, 2001-2006 (units)
Figure 5-102. Active wells as percentage of the total operating well stock in the North Caucasus (%)
Figure 5-103. Well-servicing jobs in the North Caucasus by company, 2001-2006
Figure 5-104. Well-workover jobs in the North Caucasus by company, 2001-2006
Figure 5-105. Artificial lift optimization jobs in the North Caucasus by company, 2001-2006 (units)
Figure 5-106. Effectiveness of artificial lift optimization activities in the North Caucasus, 2001-2006 (flow rate- tons per day)
Figure 5-107. Bottom-hole zone treatment jobs in the North Caucasus by company, 2001-2006 (units)
Figure 5-108. Effectiveness of bottom-hole zone treatment activities in the North Caucasus, 2001-2006 (incremental flow rate- tons per day)
Figure 5-109. Number of hydraulic fracturing jobs in the North Caucasus by company, 2004-2006 (units)
Figure 5-110. Effectiveness of hydraulic fracturing activities in the North Caucasus, 2004-2006 (incremental flow rate- tons per day)
Figure 5-111. Water injection in the North Caucasus by company (thousands of cubic meters)
Figure 5-112. Water injection per ton of production in the North Caucasus, 2001-2006 (tons of water per ton of oil)
Figure 5-113. Oil production in Eastern Siberia by company, 2001-2006 (thousands of tons
Figure 5-114. Oil production in the Far East by company, 2001-2006 (thousands of tons)
Figure 5-115. Oil production in the Far East – Key production activities, 2001-2006 (thousands of tons)
Figure 5-116. Production drilling in the Far East by company, 2001-2006 (thousands of meters)
Figure 5-117. Commissioning of new production wells in the Far East by company, 2001-2006 (units)
Figure 5-118. Estimates of flow rates from new wells and average depths in the Far East, 2001-2006
Figure 5-119. Estimates of flow rates from new wells and average depths at Sakhalinmorneftegas, 2001-2006
Figure 5-120. Exploration drilling in the Far East by company, 2001-2006 (thousands of meters)
Figure 5-121. Total producing well stock in the Far East, 2001-2006 (units)
Figure 5-122. Active wells as percentage of the total operating well stock in the Far East, 2001-2006 (%)
Figure 5-123. Well-servicing jobs in the Far East by company, 2001-2006 (light workovers – number of operations)
Figure 5-124. Well-workover jobs in the Far East by company, 2001-2006 (heavy workovers – number of operations)
Figure 5-125. Artificial lift optimization jobs in the Far East by company, 2001-2006 (units)
Figure 5-126. Effectiveness of artificial lift optimization activities in the Far East, 2001-2006 (flow rate- tons/day)
Figure 5-127. Bottom-hole zone treatment jobs in the Far East by company, 2001-2006 (units)
Figure 5-128. Effectiveness of bottom-hole zone treatment activities in the Far East, 2001-2006 (incremental flow rate- tons/day)
Figure 5-129. Water injection in the Far East by company, 2001-2006 (thousands of cubic meters)
Figure 5-130. Water injection per ton of production in the Far East, 2001-2006 (tons of water per ton of oil)
Figure 6-1. Oil production by VIOCs and independent producers in Russia, 2001-2006 (millions of tons per year)
Figure 6-2. Estimates on core oilfield services cost by companies in 2006 (millions of dollars)
Figure 6-3. Structure of companies' core oilfield services expenditures in 2006 (millions of dollars)
Figure 6-4. Apparent costs of core oilfield services in 2006 (US dollars per 1 ton of produced oil)
Figure 6-6. Rosneft’s oil production by region in current asset structure, 2000- 2006 (millions of tons)
Figure 6-7. Main financial indices of Rosneft adjusted per 1 ton of produced oil, 2000-2006 ($/t)
Figure 6-9. Rosneft’s drilling and equipment costs, 2001-2006 (millions of US dollars)
Figure 6-10. Scope of production drilling by Rosneft by region, 2001-2006 (thousands of meters)
Figure 6-11. Scope of exploratory drilling by Rosneft by region, 2000-2006 (thousands of meters)
Figure 6-12. Horizontal drilling by Rosneft by region, 2001-2006 (thousands of meters)
Figure 6-13. Rosneft’s estimated daily flow rate of new wells, 2000-2006 (tons per day)
Figure 6-14. Rosneft’s estimated daily flow rate caused by the impact on the effective drainage area, 2000-2006 (tons per day)
Figure 6-15. Rosneft’s estimated daily flow rate caused by hydro fracs, 2004-2006 (tons per day)
Figure 6-16. Rosneft’s estimated daily flow rate caused by artificial lift optimization, 2000-2006 (tons per day)
Figure 6-18. LUKOIL's oil production by region, 2001-2006 (millions of tons)
Figure 6-19. Main financial indices of LUKOIL, 2001-2006 adjusted per 1 ton of oil produced ($/t)
Figure 6-21. Reported drilling and equipment expenses of LUKOIL, 2001-2006 (millions of US dollars)
Figure 6-22. Reported seismic exploratory works, carried out by LUKOIL, 2001-2006
Figure 6-23. Scope of development drilling by LUKOIL by region, 2001-2006 (thousands of meters)
Figure 6-24. Scope of exploratory drilling by LUKOIL by region, 2001-2006 (thousands of meters)
Figure 6-25. Scope of horizontal drilling by LUKOIL by region, 2001-2006 (thousands of meters)
Figure 6-26. Prospecting and exploration drilling by LUKOIL in Northern Caspian, 2000-2006 (thousands of meters)
Figure 6-27. The share of third-party and in-house contractors of LUKOIL in carrying out service works (%)
Figure 6-28. LUKOIL’s estimated daily flow rate on new wells, 2000-2006 (tons per day)
Figure 6-29. LUKOIL’s estimated daily flow rate caused by impact on the effective drainage area, 2000-2006 (tons per day)
Figure 6-30. LUKOIL’s estimated daily flow rate with hydro fracs, 2004-2006 (tons per day)
Figure 6-31. LUKOIL’s estimated daily flow rate due to artificial lift optimization, 2000-2006 (tons per day)
Figure 6-33. Oil production by TNK-BP by region, 2000-2006 (millions of tons)
Figure 6-34. Main financial indices of TNK-BP*, 2002-2006 adjusted per 1 ton of produced oil
Figure 6-36. TNK-BP's drilling and equipment expenses, 2001-2006 (millions of US dollars)
Figure 6-37. Production drilling performed by TNK-ÂÐ by region, 2000-2006 (thousands of meters)
Figure 6-38. Scope of exploratory drilling by TNK-BP by region, 2000-2006 (thousands of meters)
Figure 6-39. The scope of horizontal drilling by TNK-BP by region, 2002-2006 (thousands of meters)
Figure 6-40. TNK-BP estimated daily flow rate on new wells, 2000-2006 (tons per day)
Figure 6-41. TNK-BP estimated daily flow rate caused by impact on the effective drainage area, 2000-2006 (tons per day)
Figure 6-42. TNK-BP estimated daily flow rate caused by hydro fracs, 2004-2006 (tons per day)
Figure 6-43. TNK-BP estimated daily flow rate caused by artificial lift optimization, 2000-2006 (tons per day)
Figure 6-45. Oil production by Sibneft by region, 2000-2006 (millions of tons)
Figure 6-46. Main financial indices of Sibneft, 2001-2006 as adjusted per 1 ton of produced oil
Figure 6-48. Sibneft’s drilling and equipment expenses, 2001-2006 (millions of US dollars)
Figure 6-49. The scope of seismic work carried out by Sibneft, 2000-2005
Figure 6-50. The scope of production drilling by Sibneft by region, 2000- 2006 (thousands of meters)
Figure 6-51. Scope of exploratory drilling by Sibneft by region, 2000-2006 (thousands of meters)
Figure 6-52. Scope of horizontal drilling by Sibneft by region, 2001-2006 (thousands of meters)
Figure 6-53. Gazprom neft’s estimated daily flow rate of new wells, 2000-2006 (tons /day)
Figure 6-54. Gazprom neft’s estimated daily flow rate caused by the impact on the effective drainage area, 2000-2006 (tons per day)
Figure 6-55. Gazprom neft’s estimated daily flow rate caused by hydro fracs, 2004-2006 (tons per day)
Figure 6-56. Gazprom neft’s estimated daily flow rate caused by artificial lift optimization, 2000-2006 (tons perday)
Figure 6-58. Oil production by Russneft by region in 2006 asset structure, 2000-2006 (millions of tons)
Figure 6-59. Main financial indices of Russneft, 2003-2006, adjusted per 1 ton of produced oil (RAS)
Figure 6-61. Scope of production drilling by Russneft by region, 2000-2006 (thousands of meters)Figure 6-62. Scope of exploratory drilling by Russneft by region, 2000-2006 (thousands of meters)
Figure 6-63. Scope of horizontal drilling by Russneft by region, 2003-2006 (thousands of meters)
Figure 6-64. Russneft estimated daily flow rate at new wells, 2000-2006 (tons per day)
Figure 6-65. Russneft apparent daily flow rate caused by the impact on the effective drainage area, 2000-2006 (tons per day)
Figure 6-66. Russneft estimated daily flow rate due to hydro fracs, 2000-2006 (tons per day)
Figure 6-67. Russneft estimated daily flow rate due to optimization of artificial lift, 2000-2006 (tons per day)
Figure 6-69. Oil production by Surgutneftegas in key regions, 2000-2006 (millions of tons)
Figure 6-70. Main financial indices of Surgutneftegas, 2001-2006, adjusted per 1 ton of produced oil (RAS)
Figure 6-72. Drilling and equipment expenses of Surgutneftegas, 2001-2006 (millions of US dollars)
Figure 6-73. Production drilling by Surgutneftegas by region, 2000-2006 (thousands of meters)
Figure 6-74. Exploratory drilling by Surgutneftegas by region, 2001-2006 (thousands of meters)
Figure 6-75. Horizontal drilling by Surgutneftegas by region, 2000-2006 (thousands of meters)
Figure 6-76. Surgutneftegas’ estimated daily flow rate at new wells, 2000-2006 (tons per day)
Figure 6-77. Surgutneftegas’ estimated daily flow rate caused by the impact on the effective drainage area, 2000-2006 (tons per day)
Figure 6-78. Surgutneftegas’ estimated incremental daily flow rate from hydro fracs, 2000-2006 (tons per day)
Figure 6-79. Surgutneftegas’ estimated incremental daily flow rate due to artificial lift optimization, 2000-2006 (tons per day)
Figure 6-81. Oil production by Slavneft, 2000-2006 (millions of tons)
Figure 6-82. Main financial indices of Slavneft, 2005-2006, adjusted per 1 ton of produced oil
Figure 6-84. Scope of 2D and 3D exploration seismology carried out by Slavneft, 2000-2005
Figure 6-85. Slavneft’s production drilling, 2001-2006 (thousands of meters)
Figure 6-86. Slavneft’s exploratory drilling, 2001-2006 (thousands of meters)
Figure 6-87. Horizontal drilling by Slavneft by region, 2000-2006 (thousands of meters)
Figure 6-88. Slavneft’s estimated flow rate on new wells, 2000-2006 (tons per day)
Figure 6-89. Slavneft’s estimated daily flow rate caused by the impact on the effective drainage area, 2000-2006 (tons per day)
Figure 6-90. Slavneft’s estimated daily flow rate caused by hydro fracs, 2000-2006 (tons per day)
Figure 6-91. Slavneft’s estimated daily flow rate caused by artificial lift optimization, 2000-2006 (tons per day)
Figure 6-93. Oil production by Tatneft by region, 2000-2006 (millions of tons)
Figure 6-94. Main financial indices of Tatneft, 2000-2006, adjusted per 1 ton of produced oil
Figure 6-96. Production drilling by Tatneft by region, 2001-2006 (thousands of meters)
Figure 6-97. Scope of exploratory drilling by Tatneft by region, 2000-2006 (thousands of meters)
Figure 6-98. Scope of horizontal drilling by Tatneft by region, 2000-2006 (thousands of meters)
Figure 6-99. Tatneft’s estimated daily flow rate on new wells, 2000-2006 (tons per day)
Figure 6-100. Tatneft’s estimated daily flow rate caused by the impact on the effective drainage area, 2000-2006 (tons per day)
Figure 6-101. Tatneft’s estimated daily flow rate caused by hydro fracs, 2004-2006 (tons per day)
Figure 6-102. Tatneft’s estimated daily flow rate caused by artificial lift optimization, 2000-2006 (tons per day)
Figure 6-104. Oil production by Bashneft by region, 2000-2006 (millions of tons)
Figure 6-105. Main financial indices of Bashneft, 2002-2006, adjusted per 1 ton of produced oil
Figure 6-107. Production drilling by Bashneft by region, 2001-2006 (thousands of meters)
Figure 6-108. Exploratory drilling by Bashneft by region, 2001-2006 (thousands of meters)
Figure 6-109. Horizontal drilling by Bashneft by region, 2000-2006 (thousands of meters)
Figure 6-110. Bashneft estimated flow rate on new wells, 2000-2006 (tons per day)
Figure 6-111. Bashneft estimated flow rate caused by the impact on the effective drainage area, 2000-2006 (tons per day)
Figure 6-112. Bashneft estimated daily flow rate caused by hydro fracs, 2000-2006 (tons per day)
Figure 6-113. Bashneft estimated daily flow rate caused by artificial lift optimization, 2000-2006 (tons per day)
Figure 6-115. Crude oil and condensate production by Gazprom, 2001-2006 (millions of tons)
Figure 6-116. Financial indices of Gazprom, 2001-2006, adjusted per ton of produced oil equivalent
Figure 6-118. Production drilling by Gazprom, 2000-2006 (thousands of meters)
Figure 6-119. Exploratory drilling by Gazprom, 2000-2006 (thousands of meters)
Volume 2.
Figure 7-1. Competitive environment in the oilfield service sector in Russia
Figure 7-2. Unit cost of services, 2005-2006 (US dollars per ton of produced oil)
Figure 7-4. Market shares estimate for 2006
Figure 7-6. Horizontal wells drilled by Surgutneftegas and effect, 1995-2006 (units per year)
Figure 7-7. Fracturing operations by Surgutneftegas, 1995-2006 (units per year)
Figure 7-8. Fracturing treatment application by Surgutneftegas at existing wells and at new wells, 2001-2006 (units per year)
Figure 7-9. Effectiveness of coiled tubing units use at Surgutneftegas, 1995-2004 (thousands of tons)
Figure 7-10. Effects of well rehabilitation and sidetracking in Surgutneftegas, 1995-2005 (thousands of tons)
Figure 7-13. Organizational structure of OAO Tatneft in 2005 (annual report)
Figure 7-14. Organizational structure of the well-workover and oil recovery enhancement service of Tatneft in 2005
Figure 7-23. Revenues of Schlumberger and the share of the Russian business in the revenues of the company, 2002-2005 (millions of US dollars on the left, and the share in % on the right)
Figure 7-27. Number of well completions by drilling operations performed by PetroAlliance, 2002-2006
Figure 7-29. Actual and estimated drill footage of EDC, 2001-2006 (thousands of meters)
Figure 7-33. Main assets of Nizhnevartovskburneft in 2006
Figure 7-40. Published revenues data Baker Hughes in Russia and CIS , 2002-2007 (millions of US dollars)
Figure 7-43. Drilling by SBK, 2005-2007 (thousands of meters)
Figure 7-46. Drilling by RN-Burenie, 2005-2007 (thousands of meters)
Figure 7-51. Exploration drilling of Usinskgeoneft, 1988-2006 (thousands of meters)
Figure 7-53. Spets UBR Uvat’s stock of orders, 2004-2005
Figure 7-54. Spets UBR Uvat’s drilling activities, 1995-2006 (thousands of meters)
Figure 7-58. Drilling by Burgaz, 2002-2006 (thousands of meters)
Figure 7-77. Drilling volumes of OAO Udmurtgeologiya, 2001-2005 (thousands of meters)
Figure 7-86. Hydraulic fracturing performed by CATkoneft for main clients, 1991-2006 (number of operations)
Figure 7-91. Performed operations by Newco Well Service, 2000-9/2006 (number of operations)
Figure 7-100. Footage per drilling crew by companies in 2006
Figure 7-101. Costs of one crew-hour on well servicing by companies (light workovers), 2002-2006 (dollars per hour)
Figure 7-102. Cost of one crew-hour on well workover by companies, 2002-2006 (US dollars per hour)
Figure 7-103. Apparent revenues per well-servicing crew, 2002-2006 (thousands of US dollars per hour)
Figure 7-104. Apparent revenues per well-workover crew, 2002-2006 (thousands of US dollars per hour)
Figure 8-1. Production of drilling rigs as per Rosstat statistics, 2001-2006 (numbers of units)
Figure 8-2. Production of workover rigs as per Rosstat statistics, 2001-2006 (number of units)
Figure 8-3. Production of drilling rigs by Uralmash as reported to Rosstat, 2001-2006 (number of units)
Figure 8-6. Production of drilling rigs by Volgograd Drilling Equipment Plant as reported to Rosstat, 2001-2006 (number of units)
Figure 8-8. Production of hoist systems by Kungur Machine-Building Equipment Plant as reported to Rosstat, 2001-2006 (number of units)
Figure 8-10. Production of hoist systems by Ishimbai machine building plant as reported to Rosstat, 2001-2006 (number of units)
Figure 8-12. Production of workover rigs by OAO Mashzavod as reported to Rosstat, 2001-2006 (number of units)
Figure 8-14. Production of workover rigs by OAO Geomash as reported to Rosstat, 2001-2006 (number of units)
Figure 8-16. ESP production by major manufacturers in the Russian Federation as per Rosstat statistics, 2001-2006 (number of units)
Figure 8-17. ESP production by major manufacturers in the Russian Federation as per Rosstat statistics and production wells equipped with ESP, 2001-2006
Figure 8-18 Official reporting and estimated production of ESP, 2001-2006 (number of units)
Figure 8-19. Bottom-hole pump production in Russia as reported to Rosstat, 2001-2006 (number of units)
Figure 8-20. Bottom-hole pump production by main Russian manufacturers as reported to Rosstat and production wells with bottom-hole pumps, 2000-2006 (number of units)
Figure 8-21. Jack-up production by main manufacturers in Russia as reported to Rosstat, 2001-2006 (number of units)
Figure 8-22. Production of ESP by Borets as reported to Rosstat, 2001-2006 (number of units)
Figure 8-24. Production ESP by Lemaz as reported to Rosstat, 2001-2006 (number of units)
Figure 8-27. Production of electrical submersible pumps by ALNAS as reported to Rosstat, 2001-2006 (number of units)
Figure 8-29. Deep seated sucker rod pump production at Izhneftemash as reported to Rosstat, 2001-2006 (number of units)
Figure 8-30. Cementing unit and jack-up rig production at Izhneftemash as reported to Rosstat, 2001-2006 (number of units)
Figure 8-32. Deep seated sucker rod production at Perm Oilfield Machinery Company as reported to Rosstat, 2002-2006 (number of units)
Figure 8-34. Production of the beam pump surface units by Reduktor as reported to Rosstat, 2001-2006 (number of units)
Figure 8-36. Major manufacturers of Christmas trees for the oil industry as reported to Rosstat, 2001-2006 (number of units)
Figure 8-37. Commissioning of new wells and apparent wellhead assembly replacement, 2001-2006 (number of units)
Figure 8-38. Korvet pipe valves production data as reported to Rosstat, 2001-2006 (number of units)
Figure 8-41. Cementing unit production by main producers as reported to Rosstat, 2001-2006 (number of units)
Figure 8-42. Cementing unit production at Pervomaiskkhimmash as reported to Rosstat, 2001-2006 (number of units)
Figure 9-1. Urals price, mineral resource extraction tax (NDPI), export duty for oil (dollars per ton, left scale) and the share of the NDPI and export duty in the Urals price (% right scale), 2003-(10 months)2005
Figure 9-2. Oil price projections under the EIA scenario, 2006-2015 (US dollars per barrel)
Figure 10-2. Oil and gas condensate production in Russia, 2006-2015 (millions of tons)
Figure 10-3. Incremental production by key regions, 2007-2015, millions tons (2006 base year)
Figure 10-4. Estimated decline rate of the base production in key regions in, 2004-2006
Figure 10-5. Forecast of the number of fracturing-treatment operations in Russia, 2007-2015 (number of units)
Figure 10-6. Forecast of the number and flow rates of sidetracking in Russia, 2006-2015 (number of units)
Figure 10-7. Forecast of the effectiveness of the activities aimed at an impact on the effective drainage area and artificial lift optimization, 2007-2015 (thousands of tons)
Figure 10-8. Forecast of growth due to drilling (tons a year) and the average flow rate of new wells, 2007-2015 (tons per day)
Figure 10-9. Forecast of the number of well-servicing and workover operations and the dynamics of the producing well stock, 2007-2015
Figure 10-10. Forecast of the annualized growth in the sources of growth in production (excluding offshore), 2007- 2015 (millions of tons)
Figure 10-11. Forecasts of drill footage and production wells completions in Russia, 2006-2015
Figure 10-12. Forecast of drill footage in the major production regions, 2007-2015 (thousands of meters)
Figure 10-13. Forecast of the growth in the number of drill crews and footage per one crew, 2006-2015
Figure 10-14. Forecast of drilling rigs stock, 2007-2015 (number of units)
Figure 10-15. Forecast of drill rigs procurement, 2007-2015 (number of units)
Figure 10-16. Forecast of the growth in well-servicing and workover crews and incremental annual supply of workover rigs, 2007-2015
Figure 10-17. Forecast of the needs for workover rigs, 2007-2015
Figure 10-18. Forecast of producing wells with ESP Systems and ESP Systems sales, 2006-2015
Figure 10-19. Forecast of need in wellhead and Christmas tree fittings, 2006-2015 (number of units)
Figure 11-1. Anticipated dynamics of the oilfield services market in Russia, 2006-2015 (millions of US dollars nominal)
Figure 11-2. Anticipated contribution of the major segments into the oilfield services market increase in Russia, 2007-2015 (%)
Figure 11-3. Anticipated annual average growth in different segments of the market, 2006-2015 (%)
Figure 11-4. Anticipated dynamics of key segments in drilling in Russia, 2006-2015 (millions of US dollars)
Figure 11-5. Anticipated dynamics of the fracturing treatment segment of the market in Russia, 2006-2015 (millions of US dollars)
Figure 11-6. Anticipated dynamics of the market segment for sidetracking of idle wells in Russia, 2006-2015 (millions of US dollars)
Figure 11-7. Anticipated dynamics of the logging and seismic segments of the market in Russia, 2006-2015 (millions of US dollars)
Figure 11-8. Anticipated dynamics of the market by the major regions, 2006-2015 (millions of US dollars)
Figure 11-9. Anticipated shares of the market of the major regions, 2006-2015 (%)
Figure 11-10. Anticipated incremental to the market level of 2006 by major categories
Figure 11-11. Anticipated oilfield services expenses per ton of production (left hand scale) and per barrel (right hand scale), 2006-2015 (US dollars per ton)
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